Systems and methods for driving a pumpjack

ABSTRACT

Systems and methods for providing a pump driving unit for driving an above ground pump. The pump driving unit utilizes a single prime mover and a drive train for actuating multiple components required to drive the above ground pump. Some implementations of the pump driving unit include phase separation devices, filtering units, and cooling units that may also be actuated by the drive train of the unit. Some implementations of the pump driving unit further include an enclosure and a platform for containing the unit and simplifying on-site installation.

1. RELATED APPLICATIONS

This application is a continuation in part of co-pending utilityapplication Ser. No. 12/202,108 filed Aug. 29, 2008, entitled “SYSTEMSAND METHODS FOR DRIVING A SUBTERRANEAN PUMP.”

BACKGROUND OF THE INVENTION

1. Field of the Invention The present invention relates to a lowemission system for reciprocating a natural gas/oil well pumpjackassociated with a subterranean well. In particular, the presentinvention relates to systems and methods for providing modular andcombination units capable of driving a hydraulic pump or motor which inturn drives a pumpjack, as well as other components of the system, asrequired to produce the well. The present invention further relates tosystems and methods for providing modular and combinations unit capableof driving a subterranean pump associated with a subterranean well.

2. Background and Related Art

Oil wells typically vary in depth from a few hundred feet, to severalthousand feet. In many wells there is insufficient subterranean pressureto force the oil and water to the earth's surface. For this reason, somesystem must be used to pump the crude oil, hydrocarbon gas, producedwater and/or hydrocarbon liquids of the producing formation to theearth's surface. The most common system for pumping an oil well is bythe installation of a pumping unit at the earth's surface thatvertically reciprocates a travelling valve of a subsurface pump.

Traditionally, subsurface pumps have been reciprocated by a pumpingdevice called a pumpjack which operates by the rotation of an eccentriccrank driven by a prime mover which may be an engine or an electricmotor. A mechanical mechanism such as this has been utilized extensivelyin the oil and natural gas production industry for decades and continuesto be a primary method for extracting oil from a well.

In addition to lifting gas and/or oil from the producing formation,traditional pumping systems further provide means for separating,compressing, cooling, and storing materials recovered from theassociated well. The function of lifting the gas and/or oil, combinedwith the additional functions of separating, compressing, cooling andstoring the lifted materials requires the use of multiple prime movers,motors, generators, power supplies and the like. The various primemovers or motors each require fuel and maintenance, as well as produceemissions. Thus, such mechanical systems suffer from a number ofinherent disadvantages or inefficiencies which are undesirable.

While techniques currently exist that relate to driving a pumpjack,challenges still exist. A need, therefore, exists for a dynamic pumpdriving system that overcomes the current challenges. Accordingly, itwould be an improvement in the art to augment or even replace currenttechniques with other techniques.

SUMMARY OF THE INVENTION

The present invention relates to reciprocating an oil or natural gaspumpjack associated with a subterranean well. In particular, the presentinvention relates to systems and methods for providing a dynamic,combination unit capable of driving a hydraulic portion of a pumpjacksystem, as well as other components of the system, as required. Thepresent invention further relates to driving a subterranean pumpassociated with a subterranean well.

Implementation of the present invention takes place in association withan artificial lift system for recovery of oil and/or gas from asubterranean well. In some implementations, the combination pump driveincludes a prime mover, a hydraulic pump or motor, and a compressor. Thecombination unit further includes a drive train having a jack shaftinterconnected to a plurality of pulleys and belts whereby the singleprime mover drives the various components of the combination unit. Thecombined configuration of the prime mover and the drive train eliminatesthe need for multiple prime movers or motors to operate the variouscomponents of the unit. Thus, a single prime mover is used tosimultaneously and efficiently drive the components of the unit, whichin turn drives the pumpjack associated within a subterranean well. Forexample, in one embodiment a single prime mover is used to drive boththe pumpjack and simultaneously perform other tasks, such as compressingand cooling the gas at the surface prior to storage.

In at least some implementations of the present invention, thecombination unit includes an oil-field separator, a filtration unit, acooling unit, and a storage tank. The oil-field separator is interposedbetween the wellhead and the compressor to separate the various phasesof materials lifted from the subterranean well. In some implementationsthe filtration unit is interposed between the separator and thecompressor to remove undesirable debris and particulate matter prior tocompression. In still further implementations, the cooling unit isinterposed between the filtration unit and the storage tank tosufficiently cool the compressed and liquefied gas prior to storage. Thestorage tank is provided to receive and store the lifted gases andliquids, as required by the unit.

In at least some implementations, the combination unit further includesan enclosure and a platform to contain the various components of thesystem. Additional features may include a battery and/or an alternativeenergy source to power the prime mover during operation of the unit.

While the methods, modifications and components of the present inventionhave proven to be particularly useful in the area oil and/or gasproduction, those skilled in the art will appreciate that the methods,modifications and components can be used in a variety of differentartificial lift applications.

These and other features and advantages of the present invention will beset forth or will become more fully apparent in the description thatfollows and in the appended claims. The features and advantages may berealized and obtained by means of the instruments and combinationsparticularly pointed out in the appended claims. Furthermore, thefeatures and advantages of the invention may be learned by the practiceof the invention or will be obvious from the description, as set forthhereinafter.

BRIEF DESCRIPTION OF THE DRAWINGS

In order that the manner in which the above recited and other featuresand advantages of the present invention are obtained, a more particulardescription of the invention will be rendered by reference to specificembodiments thereof, which are illustrated in the appended drawings.Understanding that the drawings depict only typical embodiments of thepresent invention and are not, therefore, to be considered as limitingthe scope of the invention, the present invention will be described andexplained with additional specificity and detail through the use of theaccompanying drawings in which:

FIG. 1 is a perspective side view of a representative embodiment of thepresent invention;

FIG. 2 is a perspective top view of the combination unit of claim 1;

FIG. 3 is a cross-sectional view of a representative hydraulic line ofan embodiment of the present invention;

FIG. 4 is a perspective side view of a representative embodiment of thepresent invention;

FIG. 5 is a perspective side view of a representative embodiment of amodular pump driving system of the present invention;

FIG. 6 is a perspective side view of a representative embodiment of acombination pump driving system of the present invention; and

FIG. 7 is a perspective side view of a representative embodiment of acombination pump driving system of the present invention.

DETAILED DESCRIPTION OF THE INVENTION

The present invention relates to reciprocating an oil or natural gaspumpjack associated with a subterranean well. In particular, the presentinvention relates to systems and methods for providing a dynamic,combination unit capable of driving a hydraulic portion of a pumpjacksystem, as well as other components of the system, as required. Thepresent invention further relates to driving a subterranean pumpassociated with a subterranean well.

It is emphasized that the present invention, as illustrated in thefigures and description herein, may be embodied in other forms. Thus,neither the drawings nor the following more detailed description of thevarious embodiments of the system and method of the present inventionlimit the scope of the invention. The drawings and detailed descriptionare merely representative of examples of embodiments of the invention;the substantive scope of the present invention is limited only by theappended claims recited to describe the many embodiments. The variousembodiments of the invention will best be understood by reference to thedrawings, wherein like elements are designated by like alphanumericcharacter throughout.

Referring now to FIG. 1, an implementation of a combination pump drivingunit 10 is shown. The combination unit 10 generally comprises a primemover 20, a hydraulic pump 30, and a compressor 40, as shown.Additionally, the combination unit 10 comprises a drive train 50 wherebythe prime mover 20 actuates the various components 30 and 40 of the unit10.

Referring now to FIGS. 1 and 2, the prime mover 20 may include anydevice capable of driving the drive train 50 of the unit 10. Forexample, in one embodiment the prime mover 20 is a natural gas poweredengine having an exhaust pipe 28. In another embodiment, the prime mover20 is an electric motor, as shown in FIGS. 4-6. In some embodiments, theprime mover 20 comprises at least one of a gas turbine, a steam turbine,a water turbine, a diesel engine, and a petrol engine. In eachembodiment, the prime mover 20 further comprises a rotor 22 extendingoutwardly from the body of the prime mover 20. The rotor 22 ispositioned and configured so as to compatibly receive a pulley 24,discussed in detail below.

In embodiments where the prime mover 20 is an electric motor, as shownin FIG. 4-7, the prime mover 20 may be powered by any electric sourceproducing sufficient wattage and amperage, as required. For example, inone embodiment the prime mover 20 is hardwired to an electrical line 76.In another embodiment, the prime mover 20 is powered by a battery 96 viaa power cord 98. The battery 96 may include any battery commonly knownin the art including galvanic cells, electrolytic cells, fuel cells, andvoltaic piles. Additionally, the battery 96 may comprise primarybatteries or secondary batteries, as required by the unit 10. Where thebattery 96 comprises secondary batteries, the battery 96 may berecharged by applying electrical current to the battery 96 via acharging source 94. The charging source may include any alternate sourceof electricity such as a wind-powered generator, a solar-poweredgenerator, a hydro-powered generator, a geothermal-powered generator, ora generator powered by a second prime mover (not shown). In oneembodiment, the battery 96 is charged via a generator or alternator (notshown) that is driven by the drive train 50 of the unit.

Additional components of the unit may include a hydraulic pump 30 and acompressor 40. The hydraulic pump 30 is well known in the art and insome embodiments may be modified to enhance the pump's operation orefficiency. For example, in one embodiment the hydraulic pump 30 is ahydrostatic pump. In another embodiment the hydraulic pump 30 ishydrodynamic. In one embodiment where the hydraulic pump 30 ishydrostatic, the displacement of the pump is fixed, such that thedisplacement through the pump 30 cannot be adjusted. In anotherembodiment where the hydraulic pump 30 is hydrostatic, the displacementof the pump is variable, such that the displacement through the pump 30is adjustable. Additional embodiments of the hydraulic pump 30 include agear pump, a gerotor pump, a rotary vane pump, a screw pump, a bent axispump, an axial piston pump, a radial piston pump, and a peristalticpump. In some embodiments, a jet pump (not shown) is substituted for thehydraulic pump 30.

The hydraulic pump 30 is provided to drive a hydraulic cylinder portion(not shown) of a down hole oil pump, or subterranean pump as commonlyused in the oil industry. As such, the hydraulic pump 30 typicallyrequires approximately 0-5000 psig to sufficiently drive thesubterranean pump. Various forms and combinations of subterranean pumpsare available and commonly used, as will be appreciated by one ofordinary skill in the art. For example, in one embodiment thesubterranean pump includes a hydraulic cylinder portion that is locatedor enclosed within the wellhead 12 and is accessible via the hydraulicport 14. In another embodiment, the subterranean pump includes ahydraulic cylinder portion that is located at the bottom of the well andis accessible via hydraulic lines connecting the hydraulic pump and thehydraulic cylinder. The hydraulic pump 30 is fluidly coupled to thehydraulic port 14 via a hydraulic line 80. The hydraulic line 80 isprovided to circulate hydraulic fluid from the hydraulic pump 30 to thesubterranean pump via the hydraulic port 14 and wellhead 12.

Referring now to FIG. 3, a cross-sectional view of an implementation ofthe hydraulic line 80 is shown. The hydraulic line 80 comprises an outertubing 82 and an inner tubing 84, the inner tubing 84 being entirelyencased within the outer tubing 82. The inner tubing 84 comprises alumen 88 of sufficient diameter to permit flow of hydraulic fluid to thesubterranean pump. As such, the inner tubing 84 acts as an egress linefrom the hydraulic pump 30. Similarly, the outer tubing 82 comprises aninner lumen 86 of sufficient diameter to both house the inner tubing 84and permit flow of hydraulic fluid from the subterranean pump to thehydraulic pump 30. As such, the outer tubing 82 acts as an ingress lineinto the hydraulic pump 30. The diameters of the outer tubing 82 and theinner tubing 84 may be configured as needed to provide sufficient supplyof hydraulic fluid to the hydraulic components of the subterranean pump.For example, in one embodiment the outer tubing 82 as an inner diameterof approximately 38 mm while the inner tubing has an inner diameter ofapproximately 19 mm. One of skill in the art will appreciate that thewellhead 12, the hydraulic cylinder, and the hydraulic pump 30 may bemodified to accommodate multiple hydraulic lines in place of thecombination hydraulic line 80, as disclosed and shown in connection withFIGS. 5 and 6, below.

Referring again to FIGS. 1 and 2, the unit 10 further comprises acompressor 40. The compressor 40 is a well known component in the art ofoil production, and is provided to compress hydrocarbon gases intohydrocarbon liquids following extraction from the well. The compressor40 may include any device capable of increasing the pressure of gasremoved from the well by reducing the volume of the gas. For example, inone embodiment the compressor 40 includes at least one of areciprocating compressor, a diaphragm compressor, a diagonal compressor,a mixed-flow compressor, an axial-flow compressor, a centrifugalcompressor, a rotary screw compressor, a rotary vane compressor, and ascroll compressor.

The compressor 40 is provided to draw gas from the wellhead 12 via a gasline 90 and then compress the gas to optimize natural gas production andincrease flow from the well. The gas line 90 is generally configured tobe in fluid communication with the wellhead such that any gas brought tothe wellhead via suction provided by the compressor 40 is directed intothe gas line 90 and subsequently drawn into the compressor 40. Followingcompression, the compressed gas exits the compressor 40 through a secondgas line 92 and is deposited into a pipeline or a storage container orcollection tank 110. One of skill in the art will appreciate that thecollection tank 110 may comprise any size and dimensions necessary toaccommodate the oil production of the unit 10. For example, in oneembodiment the collection tank 110 is an underground storage tank influid communication with the compressor 40 via the second gas line 92.

With continued reference to FIGS. 1 and 2, the various components 30 and40 of the unit 10 are actuated by the prime mover 20 via the drive train50. The drive train 50 generally comprises a system of interconnectedpulleys and belts to link the prime mover 20 to the remaining components30 and 40 of the unit 10. However, in some implementations of thepresent invention, the drive train 50 is directly coupled to the drivingcomponents 30 and 40 of the unit 10 without the use of a jack shaft orpulleys. As illustrated, the central feature of the drive train 50 is ajack shaft 52, as best shown in FIG. 2. The jack shaft 52 is generallylocated at a central position between the various components of the unit10. The jack shaft 52 generally comprises a steel or otherwise metallicmaterial rod having a length sufficient to accommodate the variouspositions of the components of the unit 10. The jack shaft 52 isrotatably secured to the enclosure 70 or the skid 72 by means of astator 74. A set of bearings (not shown) is interposed between thestator 74 and the jack shaft 52 so as to permit rotation of the jackshaft 52 relative to the stator 74.

The jack shaft 52 further comprises a master pulley 54 fixedly attachedto the jack shaft 52 at a position approximately in the same plane as arotor 22 and pulley 24 of the prime mover 20. The master pulley 54 andthe pulley 24 of the prime mover 20 are interconnected via a belt orchain 26, thereby forming a primary section 60 of the drive train 50. Asconfigured, the torque of the prime mover 20 is transferred to themaster pulley 54 via the pulley 24 and belt 26 thereby causing the jackshaft 52 to rotate relative to the stators 74. One of ordinary skill inthe art will appreciate that by varying the sizes of the master pulley54 and the prime mover 20 pulley 24, the relative rotations per minuteof the jack shaft 52 may be adjusted to accommodate the needs of theunit 10. Additionally or alternatively, the relative rotations perminute of the jack shaft 52 may be altered by varying the rotations perminute of the prime mover 20, as commonly understood in the art.

In addition to the master pulley 54, the jack shaft 52 further comprisesa plurality of slave pulleys 56 and 58. The slave pulleys 56 and 58 arefixedly attached to the jack shaft 52 at a position generally in thesame plane as an adjacent component 30 and 40. The slave pulley 56 isinterconnected to the adjacent pulley 32 of the hydraulic pump 30 viathe belt or chain 34 thereby forming a secondary section 62 of the drivetrain 50. The slave pulley 58 is interconnected to the adjacent pulley42 of the compressor 40 via the belt or chain 44 thereby forming atertiary section 64 of the drive train 50. Additional slave pulleys (notshown) may be fastened to the jack shaft 52 as desired in order to driveadditional components (not shown) of the unit 10. As configured, theprime mover 20 drives both the hydraulic pump 30 and the compressor 40via the jack shaft 52 and the various belts and pulleys of the drivetrain 50.

Referring now to FIG. 4, various additional features may be included toenhance the functionality of the unit 10. For example, as compression ofthe gas naturally increases the temperature of the gas, in oneembodiment the compressor 40 is used in combination with an inlinecooling unit 100. The inline cooling unit 100 is located on the secondgas line 92 between the compressor 40 and the storage tank 110 so as tocool the liquefied gas prior to storing the gas in the storage tank 110.In one embodiment, the cooling unit 100 comprises a plurality of coils(not shown) and a fan 102, whereby the compressed gas is circulatedthrough the plurality of coils and the fan 102 draws air through thecoils thereby cooling the compressed gas. In another embodiment, thecooling unit 100 comprises a first set of coils (not shown), a secondset of coils (not shown), a fan 102, and a coolant (not shown). As such,the first set of coils is submerged in the coolant, the compressed gasis circulated through the first set of coils, the coolant is circulatedthrough the second set of coils, and the fan 102 forces or draws airthrough the second set of coils to remove excess heat from the secondset of coils and the coolant. In another embodiment, the compressor 40is further modified to include an electric generator 104 that is drivenby the tertiary section 64 of the drive train 50. As such, the fan 102of the cooling system 100 is powered by generator 104. In an alternateembodiment, an additional pulley (not shown) is attached to the jackshaft 52 at a position adjacent the fan 108, whereby the jack shaft 52and the fan 108 are interconnected via a belt or chain 112 which drivesthe fan 108 in accordance with the cooling system 100. One of skill inthe art will appreciate that any cooling system known in the art may besuccessfully coupled with the compressor. For example, in one embodimentthe compressor 40 and the cooling unit 100 are combined into a singleunit and are commercially available as such.

Additional features may also include an oil-field separator 120 and afiltering unit 122. The oil-field separator 120 is commonly used in theoil industry and may include any device capable of reducing wellhead 12pressure so that dissolved gas associated with hydrocarbon liquids isflashed off or separated as a separate phase for compression, coolingand storage. The oil-field separator 120 generally comprises a stocktank 124 or series of tanks interposed between the wellhead 12 thecompressor 40. The stock tank 124 may further comprise a plurality ofvents or valves 126 for diverting different phase materials intoseparate storage tanks or treatment processes.

A filtering unit 122 may further be interposed between the oil-fieldseparator 120 and the compressor 40, as shown. The filtering unit 122 isprovided to further homogenize the gaseous material entering thecompressor 40 by removing debris or other unwanted materials. In someimplementations of the current invention, the filtering unit 122comprises a plurality of filtering units, the filtering units comprisingvarying sizes of porosity or filtering mediums to further homogenize thegas. One of skill in the art will appreciate that oil and gas filtersare common in the gas and oil industry and therefore the presentinvention may be configured to utilize any filtering unit 122 suitableto achieve the purpose of the combination unit 10.

Referring now to FIGS. 1, 2 and 4, some embodiments of the combinationunit 10 further comprises an enclosure 70, shown in phantom. Theenclosure 70 may include any portion of the unit 10 and may also beconfigured to enclosure the wellhead 12, as shown in FIG. 4. Theenclosure 70 is generally provided to prevent interference with thecomponents and drive train 50 of the unit 10. Therefore, in oneembodiment the enclosure 70 substantially and individually covers thedrive train 50 and each component 20, 30, 40, 96, 100, 110, 120 of theunit 10. In another embodiment, the enclosure 70 substantially coversthe unit 10 as a whole. In yet another embodiment, the enclosure 70comprises a steel mesh thereby allowing ventilation for the variouscomponents of the unit 10, yet preventing tampering therewith. Finally,in one embodiment a portion of the enclosure 70 is substantially solidto protect the unit 10 from the elements.

The combination unit 10 may also include a platform or skid 72 uponwhich the various components of the unit 10 are situated and supported.As such, the unit 10 is portable and may initially be built off site andthen installed at the wellhead 12 location. The skid 72 generallycomprises a material, such as steel, and structure sufficient towithstand the weight of the individual components 20, 30, 40, 96, 100,110, 120 as well as to provide a sturdy foundation upon which to supportthe components. In some embodiments, the skid 72 is configured tocompatibly receive and support the enclosure 70.

The combination unit 10 of the present invention is provided to replaceand/or augment current artificial lift systems, such as the jack pump.The unit 10 is solely driven by the prime mover 20, which may be poweredby any source deemed necessary, as described above. The prime mover 20is interconnected with the drive train 50 of the unit via a pulley 24and a belt 26. The drive train 50 comprises a jack shaft 52 having amaster pulley 54 coupled to the belt 26, and a plurality of slavepulleys 56 and 58 each being coupled to various components 30 and 40 ofthe unit via belts 34 and 44. The jack shaft 52 and the pulleys 54, 56,and 58 coupled thereto are rotated by the prime mover 20. As such, theslave pulleys 56 and 58 drive their respective components 30 and 40,thereby providing the actuation necessary for the components 30 and 40to perform their function. The hydraulic pump 30 is driven therebyproviding a circulation of hydraulic fluid to the hydraulic componentsof the subterranean pump, as described above. The compressor 40 isdriven thereby providing sufficient compression to the gaseous materialfrom the wellhead 12, effecting a phase change prior to storage in thestorage tank 110. As configured, the single prime mover 20 is sufficientto drive all of the components of the unit 10, which in turn drives thesubterranean pump associated with the wellhead 12. Thus, the combinationunit 10 of the present invention overcomes the deficiencies inherent inthe prior art.

Referring now to FIG. 5, the combination unit 10 may be bisected toprovide a modular pump-driving system 200 and a separate pumping unit210. The pump-driving system 200 generally comprises a prime mover 20configured to drive a drive train 50, as previously disclosed. The drivetrain 50 comprises a plurality of pulleys and belts that are positionedto transfer torque from the prim e mover 20 to the individual componentsof the pump-driving system 200. The components of the pump-drivingsystem 200 include, but are not limited to, a compressor 40 and ahydraulic pump 30. As previously discussed, the hydraulic pump 30 isprovided to drive a pump or pumping unit 210 associated with asubterranean well. In some embodiments, hydraulic lines 80 a and 80 bare coupled to the hydraulic pump 30 to facilitate ingress and egress ofhydraulic fluid between the hydraulic pump 30 and hydraulic componentsof the pumping unit 210. In some embodiments, hydraulic lines 80 a and80 b further include end couplings 180 that are adapted to permanentlyor temporarily couple the hydraulic lines 80 a and 80 b to a hydraulicportion of the pumping unit 210.

The pumping unit 210 generally comprises machinery and apparatusconfigured to lift oil or gas from a subterranean well via a wellhead12. Referring to FIG. 5, some implementations of the present inventioninclude a pumping unit 210 having a pumpjack 212. A pumpjack 212, alsoknown as a walking beam pump or a nodding donkey pump, generallyincludes a scaffold 214 pivotally coupled to a beam 216. The beam 216comprises a first end that is pivotally coupled to a pitman arm 220which in turn is pivotally coupled to a counter weight 222. The beam 216further comprises a second end that is fixedly coupled to a head 218,also known as a horse head. The head 218 is further coupled to a suckerline 224 which accesses the subterranean well via the wellhead 12.Specifics regarding the operation and mechanics of pumpjack are wellknown in the art.

In some embodiments of the present invention, the counter weight 222 ofthe pumpjack 212 is coupled to a hydraulic motor 230 via a chain or belt226. The hydraulic motor 230 is configured to drive a pulley 232 whichin turn drives or rotates a pulley portion 240 of the counter weight222. The pulley portion 240 of the counter weight 222 is rotationallysecured to a stator 250 via a rotor 252. As the pulley 232 of thehydraulic motor 230 rotates, the belt 226 rotates the pulley portion 240of the counter weight 222 to rotate the counter weight 222. As thecounter weight 222 rotates, the pitman arm 220 pivots the beam 216relative to the scaffold 214. The pivoting action of the beam 216 causesthe sucker line 224 to move laterally within the wellhead 12 to producethe well.

The hydraulic motor 230 is actuated by the hydraulic pump 30 viahydraulic lines 80 a and 80 b. In some embodiments, hydraulic lines 80 aand 80 b span extensive lengths to permit remote placement of thepumping unit 210 relative to the position of the pump driving system200. In other embodiments, hydraulic lines 80 a and 80 b are spliced andcoupled to multiple pumping units 210. As such, one pump driving unit200 is utilized to drive multiple pumping units 210. Alternatively, insome embodiments hydraulic lines 80 a and 80 b are coupled to separatepiece of equipment that is hydraulically driven but not a pumping unit210. For example, in some embodiments hydraulic lines 80 a and 80 b arecoupled to a subterranean pump. In other embodiments, hydraulic lines 80a and 80 b are coupled to a hydraulic drill. Finally, one of skill inthe art will appreciate that hydraulic lines 80 a and 80 b may becoupled to any hydraulic system both within and without the oilindustry.

Referring now to FIG. 6, an integrated pump driving unit and pumpingunit 300 is shown. The integrated unit 300 combines a pump driving unit200 and a pumping unit 210 onto a single skid 72. As such, hydrauliclines 80 a and 80 b are excluded from the design and replaced by a beltor chain 62. The belt or chain 62 directly links the torque of the jackshaft 52 to the pulley 232 of a gear reducer 310. The gear reducer 310further comprises a crank arm 312 having a first end that is directlycoupled to a system of gears within the gear reducer 310. The crank armfurther includes a second end that is directly coupled to the counterweight 222 of the pumpjack 212. Thus, as the jack shaft 52 rotates underthe power of the prime mover 20, the pulley 232 of the gear reducer 310is rotated at a determined speed. Gears (not shown) within the gearreducer 310 are configured to reduce the rotational speed of the pulley232 to achieve a desired rotational speed for the crank arm 312. As thecrank arm 312 rotates, the counterweight 222 rotates which moves thepitman arm 220 thereby transferring the rotation of the crank arm 312and the counterweight 222 into a linear motion that drives the pumpjack212.

Referring now to FIG. 7, an integrated pump driving unit 400 is shown.The integrated unit 400 combines a pump driving unit 200 and a pumpingunit 210 onto a single skid 72. However, unlike integrated unit 300,integrated unit 400 comprises a hydraulic pump 30 that is coupled to thejack shaft 52 via a belt or chain 62. Additionally, integrated unit 400includes hydraulic lines 80 a and 80 b coupling the hydraulic pump 30 toa hydraulic driven unit 402. Hydraulic driven unit 402 is provided toconvert the hydraulic pressure from hydraulic lines 80 a and 80 b intorotational movement which rotates the counterweight 222 of the pumpjack212. One of skill in the art will appreciate that the hydraulic drivenunit 402 may include any hydraulically driven motor, pump, or devicecapable of driving a jackpump 212. For example, in some embodiments thehydraulic driven unit 402 comprises a hydraulic motor, similar to thosediscussed in connection with FIG. 5 above. In other embodiments, thehydraulic driven unit 402 comprises a second hydraulic pump. Finally, insome embodiments the hydraulic driven unit 402 comprises a hydraulicgear reducer.

One of skill in the art will appreciate that the hydraulic driven unit402 may be used to accomplish tasks in addition to driving the pumpjackunit 212. For example, in some embodiments the hydraulic driven unit 402is utilized to drive both the pumpjack unit 212 and a compressor. Inother embodiments, the hydraulic driven unit 402 is utilized to driveboth the pumpjack unit 212 and a subterranean pump.

The present invention may be embodied in other specific forms withoutdeparting from its spirit or essential characteristics. The describedembodiments are to be considered in all respects only as illustrativeand not restrictive. The scope of the invention is, therefore, indicatedby the appended claims rather than by the foregoing description. Allchanges that come within the meaning and range of equivalency of theclaims are to be embraced within their scope.

1. A combination pump driving unit, comprising: a drive train having ajack shaft; a master pulley coupled to the jack shaft; a prime moverhaving a first pulley supported by a rotor; a first belt interconnectingthe first pulley and the master pulley; a first slave pulley coupled toa first portion of the jack shaft; a second slave pulley coupled to asecond portion of the jack shaft; a hydraulic pump having a secondpulley supported by a rotor; a compressor having a third pulleysupported by a rotor; a second belt interconnecting the second pulleyand the first slave pulley; a third belt interconnecting the thirdpulley and the second slave pulley, wherein the combination pump drivingunit is coupled to an above ground pump to drive the above ground pump.2. The combination unit of claim 1, further comprising a hydraulic linein fluid communication with the hydraulic pump and a hydraulic componentof the above ground pump.
 3. The combination unit of claim 1, furthercomprising a gas line in fluid communication with the compressor and awellhead.
 4. The combination unit of claim 3, further comprising anoil-field separator in fluid communication with the gas line.
 5. Thecombination unit of claim 3, further comprising a filtering unit influid communication with the gas line.
 6. The combination unit of claim1, wherein the prime mover is selected from the group consisting of anatural gas engine, a diesel engine, a petrol engine, a gas turbine, awater turbine, and an electric motor.
 7. The combination unit of claim3, further comprising a cooling unit in fluid communication with the gasline.
 8. The combination unit of claim 1, further comprising anenclosure.
 9. The combination unit of claim 1, further comprising astorage tank in fluid communication with the gas line.
 10. Thecombination unit of claim 6, wherein the electric motor is powered by abattery.
 11. The combination unit of claim 6, wherein the electric motoris powered by an alternate power source selected from the groupconsisting of a hydro-powered generator, a solar-powered generator, awind-powered generator, a geothermal powered generator, and anelectrical power line.
 12. A method for driving an above ground pump,the method comprising: providing a pump driving unit having a drivetrain coupled to a prime mover; coupling a gear reducer to a firstportion of the drive train; coupling a compressor to a second portion ofthe drive train; coupling the gear reducer to the above ground pump;providing fluid communication between a wellhead and the compressor viaa gas line, wherein the above ground pump is actuated by the gearreducer to artificially lift a substance through the wellhead and intothe gas line, whereafter the substance is compressed by compressor, thecompressor being actuated by the prime mover via the drive train. 13.The method of claim 12, wherein the drive train comprises a jack shafthaving a plurality of slave pulleys and wherein the gear reducer iscoupled to the jack shaft via a first slave pulley and the compressor iscoupled to the jack shaft via a second slave pulley.
 14. The method ofclaim 13, further comprising the step of interposing an oil-fieldseparator between the wellhead and the compressor via the gas line. 15.The method of claim 13, further comprising the step of interposing afiltering unit between the well head and the compressor via the gasline.
 16. The method of claim 13, further comprising the step ofcollecting the compressed substrate in a storage tank in fluidcommunication with the compressor.
 17. The method of claim 16, furthercomprising the step of interposing a cooling unit between the compressorand the storage tank via the gas line
 18. The method of claim 17,further comprising the step of cooling the compressed substrate prior tocollecting the compressed substrate in the storage tank.
 19. The methodof claim 18, further comprising the step of coupling the cooling unit tothe drive train.
 20. A modular pumping unit, comprising: a pump drivingunit having a drive train including a jack shaft, the jack shaft havinga master pulley, the pump driving unit further including a prime moverhaving a first pulley and a belt interconnecting the first pulley andthe master pulley, the jack shaft further having a first slave pulleycoupled to a first portion of the jack shaft, and a second slave pulleycoupled to a second portion of the jack shaft, the pump driving unitfurther including a hydraulic pump having a second pulley coupled to thefirst slave pulley of the jack shaft via the belt, and a compressorhaving a third pulley coupled to the second slave pulley of the jackshaft via the belt; and a pumping unit including a hydraulic motorcoupled to the hydraulic pump of the pump driving unit via a hydraulicline, the pump driving unit further including a pump associated with awell, the pump being coupled to the hydraulic motor, wherein the primemover drives the jack shaft which in turn drives the hydraulic pump,thereby driving the hydraulic motor to actuate the pump associated withthe well.
 21. The modular pumping unit of claim 20, further comprisingcomponents selected from the group consisting of an oil-field separator,a filtering unit, a cooling unit, a generator, a battery, and analternative power source.
 22. The modular pumping unit of claim 20,wherein the belt is a serpentine belt.
 23. The modular pumping unit ofclaim 20, wherein the belt is a plurality of belts.
 24. The modularpumping unit of claim 20, wherein the pump associate with a well is atleast one of an above ground pump and a subterranean pump.
 25. Themodular pumping unit of claim 20, further comprising a gas line fluidlyinterconnecting a wellhead and the compressor, wherein the hydraulicpump drives the s pump to artificially lift a substance to the wellheadand through the gas line to the compressor coupled thereto.
 26. Acombination pump driving unit, comprising: a prime mover; a drive traindirectly coupled to both the prime mover and a plurality of drivecomponents, the plurality of drive components being selected from thegroup consisting of (a) a hydraulic pump; (b) a compressor; (c) acooling unit; (d) a generator; (e) an alternator; (f) an alternateenergy source; (g) an oil-field separator; and (h) a second prime moverwherein the drive train actuates the plurality of drive components tosimultaneously drive an above ground pump, recover a lifted substance,and store the lifted substance from a well associated with the aboveground pump.
 27. The combination unit of claim 22, wherein thecompressor is a rotary screw compressor.